Eni SpA Form 20-F Summary
Business context and reporting period
Annual report for the fiscal year ended December 31, 2022, prepared under IFRS as issued by the IASB. The filing is not a standalone fourth-quarter report; the source text does not provide a separate Q4 income statement or cash-flow presentation. Eni operates across Exploration & Production, Global Gas & LNG Portfolio, Refining & Marketing and Chemicals, Plenitude & Power, and corporate activities.
2022 was characterized by the Russia-Ukraine war, sharply higher and unusually volatile oil and European natural-gas prices, supply-chain inflation, sanctions, and energy-security measures. Brent averaged $101.19/bbl versus $70.73/bbl in 2021; the European TTF gas price averaged approximately $40/mmBTU, versus approximately $15/mmBTU in 2021.
Key financial metrics
| Metric | 2022 | 2021 | Change |
|---|---|---|---|
| Sales from operations | €132.512bn | €76.575bn | +73% |
| Operating profit | €17.510bn | €12.341bn | +42% |
| Adjusted operating profit | €20.386bn | €9.664bn | +111% |
| Net profit attributable to Eni | €13.887bn | €5.821bn | +€8.066bn |
| Adjusted net profit | €13.301bn | €4.330bn | +207% |
| Net cash from operating activities | €17.460bn | €12.861bn | +36% |
| Capital expenditures | €8.056bn | €5.234bn | +54% |
| Shareholders’ equity including non-controlling interests | €55.230bn | €44.519bn | +24% |
| Finance debt including lease liabilities | €31.868bn | €33.131bn | -4% |
| Net borrowings excluding IFRS 16 lease liabilities | €7.026bn | €8.987bn | -22% |
| Leverage excluding IFRS 16 | 0.13 | 0.20 | Improved |
| Dividend per share | €0.88 | €0.86 | +2% |
Reported operating margin was approximately 13.2% and reported net margin approximately 10.5%, based on consolidated sales from operations. Cash and cash equivalents were €10.155bn at year-end, while financial assets at fair value through profit or loss were €8.251bn. Eni also reported approximately €8.3bn of liquidity-portfolio securities and €8.3bn of committed borrowing facilities.
Segment and operating performance
- Exploration & Production: operating profit was €15.908bn versus €10.066bn. Average hydrocarbon production declined 5% to 1.487 million barrels of oil equivalent per day. Proved reserves were 6,614 mmboe, broadly stable versus 6,628 mmboe in 2021. E&P capital expenditures increased approximately 60% to €6.362bn.
- Global Gas & LNG Portfolio: operating profit rose to €3.730bn from €0.899bn, supported by portfolio optimization, contract renegotiations and extreme European gas-market volatility. Worldwide gas sales declined 14.1% to 60.52 bcm, and Russian gas supplies fell to 28% of total supplies from 43% in 2021.
- Refining & Marketing: underlying operating profit increased to €2.183bn from a €46m loss, benefiting from strong refining margins, product demand recovery and improved plant availability. Eni’s SERM averaged approximately $8.5/bbl versus negative $0.9/bbl in 2021.
- Chemicals: adjusted operating loss was €254m versus adjusted profit of €198m. Weak demand, competition from Middle and Far East producers and higher gas-linked utility costs led to a €385m impairment of petrochemical assets.
- Plenitude & Power: reported operating loss was €825m, primarily reflecting commodity-derivative effects. Adjusted operating profit was €615m. Renewable installed capacity reached 2,198 MW, nearly double 2021, and the customer base exceeded 10 million retail delivery points.
Material changes and unusual items
- Formation of Azule Energy with bp resulted in a significant gain. Eni recognized approximately €2.542bn of net investment gains, including a capital gain from contributing Angolan assets and €764m of recycled foreign-exchange gains.
- Extraordinary energy-profit taxes and levies in Italy, Germany and the United Kingdom reduced 2022 net income by approximately €2.4bn; approximately €1.1bn was paid in cash during the year, with additional cash payments expected in 2023.
- Environmental and remediation charges were approximately €2.056bn, including a €1.245bn provision for groundwater remediation at Italian brownfield sites.
- Net impairment losses were €1.140bn, including upstream impairments and approximately €385m relating to chemicals plants. Eni also recognized a €300m provision for decommissioning refinery production lines assessed as unlikely to restart.
- Carbon-allowance purchases totaled approximately €950m for 16.73 million tonnes of CO2 emissions, versus €660m in 2021.
- Cash returned to shareholders was approximately €5.4bn, including dividends and a €2.4bn share repurchase program. Eni repurchased approximately 195.6 million shares in 2022.
Guidance, outlook and management commentary
- For 2023, management assumed Brent at $85/bbl, European TTF gas at approximately $26–28/mmBTU, SERM at approximately $7/bbl and an average EUR/USD rate of $1.03 per euro.
- Management expects 2023 operating cash flow and earnings to decline from 2022 under these lower commodity-price assumptions. Cash flow sensitivity was estimated at approximately €130m for each $1/bbl change in Brent and approximately €130m for each $1/mmBTU change in European gas prices; the filing also estimates approximately €140m sensitivity to each $1/bbl change in SERM.
- 2023 capital expenditures are expected to be approximately €9.5bn, up from €8.056bn in 2022. Hydrocarbon production is expected at 1.63–1.67 million boe/d.
- The 2023–2026 plan contemplates approximately €37bn of capital expenditures, including €23bn for oil and gas projects, €5bn for renewables and Plenitude, €1.2bn for CCS and agricultural feedstock, €3.4bn for biofuels and refining, and €1.3bn for chemicals.
- Management expects to replace 100% of Russian gas supplies by 2025 through increased supplies from Algeria, Egypt, Congo, Qatar, Libya and other sources.
- Management targets leverage of approximately 0.20–0.25 during the plan period and intends to distribute 25%–30% of annual operating cash flow before working-capital changes through dividends and buybacks. The planned 2023 dividend is €0.94 per share, subject to applicable approvals, and a €2.2bn buyback was planned.
Principal risks and contingencies
- High sensitivity to crude oil, natural-gas, refining-margin, foreign-exchange and interest-rate volatility. Management estimates approximately €130m cash-flow sensitivity to a $1 change in Brent and to a $1/mmBTU change in TTF.
- European gas-market liquidity, margin-call and collateral risks; Eni reduced some hedging activity and retained more commodity exposure unhedged during the 2022 crisis.
- Russian supply disruption, sanctions compliance, take-or-pay and ship-or-pay obligations, and uncertain outcomes of contract renegotiations or arbitration.
- Political and operating risks in Libya, Nigeria, Venezuela, Kazakhstan, Mozambique and other non-OECD jurisdictions. Venezuela receivables from PDVSA were €566m net of an approximately 53% expected-credit-loss rate.
- Environmental, health, safety, decommissioning, climate litigation and regulatory risks. Total provisions were €15.267bn, including €9.322bn for site restoration and abandonment and €3.503bn for environmental matters.
- Long-term energy-transition risks include lower hydrocarbon demand, carbon pricing, higher compliance costs, stranded assets, reduced access to financing and increased competition from renewables, electric vehicles and alternative fuels.
- Contractual commitments totaled €77.481bn, while principal purchase obligations totaled €207.980bn, including €201.766bn under gas take-or-pay contracts. These are contractual commitments and should not be treated as equivalent to balance-sheet debt.
- PwC reported an unqualified audit opinion and concluded that internal control over financial reporting was effective as of December 31, 2022. Critical audit matters included proved-reserve estimates and recoverability of E&P property, plant and equipment.
Facts investors should verify
- Reconcile reported net profit of €13.887bn with adjusted net profit of €13.301bn and identify the impact of the Azule gain, windfall taxes, environmental provisions, impairments and deferred taxes.
- Assess whether 2023 commodity-price assumptions remain appropriate, particularly Brent at $85/bbl and TTF at $26–28/mmBTU.
- Review cash conversion after €9.5bn of planned 2023 capital expenditures, shareholder distributions, windfall-tax payments and potential working-capital or margin-call requirements.
- Examine the sustainability of 2022 GGP and refining profitability given management’s statement that 2022 market conditions were exceptional.
- Monitor replacement of Russian gas supplies, take-or-pay exposures, sanctions-related developments and associated arbitration proceedings.
- Evaluate reserve quality and development funding: proved reserves were 6,614 mmboe, 37% of reserves were undeveloped, and estimated future development and decommissioning costs were approximately €44.3bn undiscounted.
- Review environmental provisions, legal proceedings, guarantees and commitments, including the €1.405bn maximum third-party guarantee for certain Mozambique Area 4 obligations and the €13bn gross contractual gas-delivery exposure associated with Cardón IV, which Eni states is not the same as its expected financial exposure.